Real Time Production and Reservoir Management Petrobras Vision. Manoel Feliciano - Petrobras Sthener Campos - Petrobras

Transcription

1 Real Time Production and Reservoir Management Petrobras Vision Manoel Feliciano - Petrobras Sthener Campos - Petrobras

2 Company Overview Gas Exploration Drilling Production Distribuition Refining & Petrochemical Transportation Products Energy

3 Company Overview Proved Reserves 10.5 billion boe (SPE) Oil & gas Production: million boe/d 1.6 billion scf/d 14 Refineries Processing Capacity: 1.8 million bpd Pipelines: 14,267 km Active Wells 9,842 (852 offshore) Production Platforms 96 (74 fixed; 22 floating) Revenues US$ 22.6 billion Petrobras Employees R&D Investiment US$ 197 million /year Fertilizers 2 Plants Ammonia: 1,738 metric tons Urea: 1,927 metric tons Over service stations (33% brazilian marketshare) 2002 DATA

4 Research & Development Center S&T Afiliates: 25 Multiclient Projects: Facilities Total Area: 122,000 m 2 Constructed Area: 45,000 m Laboratories 30 Pilot Units Expansion S&T Afiliates: 13 Universities and Research Institutes agreements: 226 Anual Production Capacity 180 R&D projects 20 Basic Egineering Projects Over 1,800 Technical Support

5 Real Time Production and Reservoir Management Figura de um campo offshore BASE OF VALUES - Loss of Setorial Identity - Communication / Integrated Work - Represented Decision SUBSEA TECHNOLOGY FLOW & ARTIFICIAL LIFT TECHNOLOGY WELL TECHNOLOGY RESERVOIR TECHNOLOGY - Subsea equipments -Data Transmission / actuators -Integration Reservoir-production + -Multiphase measurement -Artificial Lift Automation -Integration Reservoir-production + - Intelligent Well Completion - Integration Reservoir-production + - Reservoir Modeling - Integration Reservoir-production System Integration /Optimization / Production diagnostics Real Time Field Management

6 Associated Technologies on Intelligent Fields Artificial Lift Automation Systems. Intelligent Well Completion. Real Time Reservoir Management. Downhole and Subsea Monitoring Systems. Decision-Making Support Systems. Processing and Integration Data Systems. Economic and Risk Analysis. Strategic Targets for Petrobras Heavy oil exploitation Mature oil field management Water injection management Maintenance of economic production rate per well Application on new field development Operational excellence

7 Field Production Optimization Backpressure Ambient Temperature Flow Restrictions Injection Fluid Restriction Measured Disturbances Unmeasured Disturbances Reservoir Rock Heterogeneity Reservoir Fluid Distribution Scheduling Feed forward path Manipulated Inputs Flow Choke Zone Control ESP Speed Unmeasured Outputs Controller Gas Lift Solvent Injection Agua Crudo Gas Reservoir Pressure: p res Reservoir Saturations: S o, S w Water Injection Heat Injection Gas Injection Flow Impairment: S, Kr s Zone Multiphase Flow: q o, q w, g q Drainage Area: A Feed back path Tubing Head Pressure: p THP Tubing Head Temperature: T THT Multiphase Flow: q o, q w, g q Solid Production, Water Analysis Well flowing Pressure: p wf Measured Outputs M. Economides 2004 ASME Gas lift Workshop

8 Production Optimization Artificial Lift Automation Concept Methodology of production in real time based on identification, modeling and controlling of process variables that compose the several artificial lift methods. Applied by programming control algorithms executed on PLCs. Challenges 1. Multiphase measurement in real time 2. Instrumentation reliability 3. Coupling Surface and downhole variables 4. Operacional Skepticism

9 Artificial Lift Management Fully dependent on the ability to measure the production in real time Petrobras has different approaches on assets around Brazil. Solutions are dependent on regional management strategy Low cost - technology domain operational excellence Case 1 UN-BSOL GOR 1000 m³/m³ API 40º- 45º Strategy: DP Estimation on surface Contact: Durval Florêncio durvalfilho@petrobras.com.br Case 3 UN-BA GOR 50 m³/m³ API 20º- 30º Strategy: Operational Pattern Identification Contact: Jose Franscisco Correa jfcorrea@petrobras.com.br Case 2 UN-RNCE GOR 50 m³/m³ API 22º- 30º Production measurment: Pwf Contact: Edson Bolonhini bolonhini@petrobras.com.br Case 4 UN-BC GOR 100 m³/m³ API 15º- 30º Strategy: Pwf / multiphase meters / DP Contact: Galileu Henke galileu@petrobras.com.br

10 Case 1 UN-BSOL

11 Case 1 UN-BSOL

12 Test Informations PVT - Oil Sitio Novo API Gas density Water Salinity = 0 Viscosity (40 oc; 10kgf /cm²) 90 cp (60 oc; 10kgf /cm²) 50 cp Investigation Strategy Construction of pilot in multiphase loop Instrument Validation Loop running with gas Test with loop in bypass configuration water and gas Test with loop in bypass - Óil + different gas fraction Teste with loop Óleo + different gas fraction Optimization production simulation Automação applied on artificial Lift

13 Multiphase Loop Test SEPARATOR Oil/Emulsion Vessel MEASURE LIQUID BSW GAS VESSEL Bypass MULTIPHASE LOOP 200 m x 6 DP Estimation UNBSOL

14 Loop in Bypass - Water + gas Liquid variation for constant gas injection Results 14:47:53 14:52:05 14:56:26 15:00:37 15:04:50 15:09:02 15:13:15 15:17:27 15:21:39 15:25:52 15:30:04 15:34:15 15:38:28 15:42:40 15:46:52 Time DP In H2O Flow rate m3/h Fraction (%) Oil = 1,6 / Water = 98,4 / Gas = 74,45 PDT-Jus InH2O DP-Mont InH2O Hw Gas injection Q_oil Separator m3/h Q_ Liq_Sitio m3/h

15 Results Loop without Bypass - Oil+ Gas PDT-Mont Q_gas Sitio DP - In H2O Flow rate m3/h Q_oil Sitio m3/h :47 14:40 16:25 Time Fractions(%) Q_oil Separator m3/h Oil = 98 / Water = 1,2 / Gas = 90

16 Case 2 UN-RNCE PID action Gas compressor shutdown Reactivation algorithm Gas compressor start-up :00:00 08:00:00 10:00:00 12:00:00 14:00:00 16:00:00 18:00:00 Hora da Aquisição 20:00:00 22:00:00 00:00:00 02:00:00 04:00:00 06:00:00 Tubing head pressure [kgf/cm 2 ] Ambient temperature [ o C] Control valve Opening [%] Gas-lift injection rate [Mm 3 /d] Casing pressure set point [kgf/cm 2 ] Casing head pressure [kgf/cm 2 ] Gas-lift injection pressure [kgf/cm 2 ] Bottom hole pressure [kgf/cm 2 ]

17 Case 4 UN-BC 5:49:10 PM 5:15:09 PM Gas Lift process Variable correlation 4:57:26 PM 4:39:45 PM 4:22:04 PM 4:04:23 PM 3:46:42 PM 3:28:56 PM 3:11:09 PM 2:53:23 PM Q_oil t_oil Qgi Time Temperature oc Gas Lift injection rate [m3/h]

18 Case 4 UN-BC External Disturbance 41 40, , , ,5 Q_oil t_oil 37 36, ,5 2:53:23 PM 3:00:24 PM 3:07:26 PM 3:14:28 PM 3:21:29 PM 3:28:31 PM 3:35:34 PM 3:42:35 PM 3:49:33 PM 3:56:34 PM 4:03:33 PM 4:10:33 PM 4:17:32 PM 4:24:31 PM 4:31:30 PM 4:38:29 PM 4:45:29 PM 4:52:28 PM 4:59:28 PM 5:06:28 PM 5:13:28 PM 5:36:43 PM 5:43:44 PM 5:50:47 PM 5:57:47 PM 6:04:47 PM 6:11:48 PM 6:18:48 PM 6:25:47 PM 6:32:47 PM 6:39:47 PM 6:46:48 PM 6:53:48 PM Time Flow rate[m3/h] Temperature [oc] Estabilization Period based on Temperature

19 Low Cost Downhole Measurements Fiber Optic Technology Pressure and Temperature Monophase Flow Multiple points (up to 12 same fiber) Single cable Focus on reliability

20 Intelligent Well Case 1: Marlin Sul Field in the Campos Basin Injection Well: 8-MLS-67HA-RJS Production Well : 4-RJS-382 Water Depth : 1168 m Umbilical: 6 Km (tied back to P-40 floating production vassel) Two reservoirs MLS-100 (with gas-oil contact) and MLS-200 (without gas-oil contact) The target : avoid increasing gas production of MLS-100 at production well by injection control in the two different reservoirs at injection well.

21 Intelligent Well Case 2: Roncador Field in the Campos Basin Injection Well: 8-RO-35D-RJS Water Depth : 1890 m Umbilical: 15,5 Km (tied back to Brazil FPSO) Reservoir intervals: RO-410, RO-420 and RO-430 The targets: - increasing oil recovery fator by selective injection in the three different intervals. - less number of interventions for injectivity tests.

22 Technological Gaps Low cost multiphase individual well production measurements Update of unmeasured reservoir variables for modeling validation Downhole measurement reliability Operational Skepticism Artificial lift methods with high intervention rates Maximum distance between well head and production unit Multilateral wells (with selectivity) Horizontal well with sand control (drift restriction) Wet mateable fiber optic connector (x-tree and disconnection tool )

23 Discussions How dynamic is a well process? What is better semi-automatic systems or self-operated systems? Model validation for close loop reservoir Technology frontiers for intelligent fields Flexibility of artificial lift methods due to reservoir management

24 Conclusions Real Time Production and Resevoir Management Advantages Reservoir Management Enhancement Production optimization Increase recovering factor Reduce reservoir interventions Reduce number of wells Eliminate the interventions for data logging Disadvantages Cost per well is increased More complicated wells More interventions due to equipment Very few experience with the Technology

25 End Thank you very much!!! Very good reason for Well Automation Development